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  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G2/00—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon
  • C10G2/30—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen
  • C10G2/32—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen with the use of catalysts
  • C10G2/33—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen with the use of catalysts characterised by the catalyst used
  • C10G2/331—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen with the use of catalysts characterised by the catalyst used containing group VIII-metals
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  • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
  • C01B3/02—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen
  • C01B3/32—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air
  • C01B3/34—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents
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  • C01B3/02—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen
  • C01B3/32—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air
  • C01B3/34—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents
  • C01B3/38—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents using catalysts
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  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G2/00—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon
  • C10G2/30—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen
  • C10G2/32—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen with the use of catalysts
  • C10G2/34—Apparatus, reactors
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  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
  • C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
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  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
  • C10K3/00—Modifying the chemical composition of combustible gases containing carbon monoxide to produce an improved fuel, e.g. one of different calorific value, which may be free from carbon monoxide
  • C10K3/02—Modifying the chemical composition of combustible gases containing carbon monoxide to produce an improved fuel, e.g. one of different calorific value, which may be free from carbon monoxide by catalytic treatment
  • C10K3/026—Increasing the carbon monoxide content, e.g. reverse water-gas shift [RWGS]
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  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
  • C10K3/00—Modifying the chemical composition of combustible gases containing carbon monoxide to produce an improved fuel, e.g. one of different calorific value, which may be free from carbon monoxide
  • C10K3/06—Modifying the chemical composition of combustible gases containing carbon monoxide to produce an improved fuel, e.g. one of different calorific value, which may be free from carbon monoxide by mixing with gases
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  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/02—Processes for making hydrogen or synthesis gas
  • C01B2203/0205—Processes for making hydrogen or synthesis gas containing a reforming step
  • C01B2203/0211—Processes for making hydrogen or synthesis gas containing a reforming step containing a non-catalytic reforming step
  • C01B2203/0216—Processes for making hydrogen or synthesis gas containing a reforming step containing a non-catalytic reforming step containing a non-catalytic steam reforming step
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  • C01—INORGANIC CHEMISTRY
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  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/02—Processes for making hydrogen or synthesis gas
  • C01B2203/0205—Processes for making hydrogen or synthesis gas containing a reforming step
  • C01B2203/0227—Processes for making hydrogen or synthesis gas containing a reforming step containing a catalytic reforming step
  • C01B2203/0244—Processes for making hydrogen or synthesis gas containing a reforming step containing a catalytic reforming step the reforming step being an autothermal reforming step, e.g. secondary reforming processes
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  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/06—Integration with other chemical processes
  • C01B2203/062—Hydrocarbon production, e.g. Fischer-Tropsch process
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/12—Feeding the process for making hydrogen or synthesis gas
  • C01B2203/1205—Composition of the feed
  • C01B2203/1211—Organic compounds or organic mixtures used in the process for making hydrogen or synthesis gas
  • C01B2203/1235—Hydrocarbons
  • C01B2203/1241—Natural gas or methane
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/12—Feeding the process for making hydrogen or synthesis gas
  • C01B2203/1258—Pre-treatment of the feed
  • C01B2203/1264—Catalytic pre-treatment of the feed
  • C01B2203/127—Catalytic desulfurisation
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/14—Details of the flowsheet
  • C01B2203/148—Details of the flowsheet involving a recycle stream to the feed of the process for making hydrogen or synthesis gas
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
  • C10G2300/10—Feedstock materials
  • C10G2300/1025—Natural gas
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
  • C10G2400/20—C2-C4 olefins
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
  • C10G2400/22—Higher olefins
• • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
  • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
  • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
  • Y02P30/00—Technologies relating to oil refining and petrochemical industry
  • Y02P30/40—Ethylene production

Definitions

• Syngas mixtures of hydrogen and carbon monoxide
• synthesis gas can be readily produced from coal, methane (natural gas), or any carbonaceous feedstock by methods well known in the art and widely commercially practiced around the world.
• a number of well-known industrial processes use syngas for producing various oxygenated organic chemicals, The Fischer-Tropseh (“FT”) catalytic process for catalytically producing hydrocarbons from syngas was initially discovered and developed in the 1920's, and was used in South Africa for many years to produce gasoline range hydrocarbons as automotive fuels.
• FT Fischer-Tropseh
• the catalysts typically comprised iron or cobalt supported on alumina or titania, and promoters, like rhenium, zirconium, manganese, and the like were sometimes used with cobalt catalysts, to improve various aspects of catalytic performance.
• the products were typically gasoline-range hydrocarbon liquids having six or more carbon atoms, along with heavier hydrocarbon products.
• the invention in one aspect, relates to methods comprising:
• the converting step comprises contacting the syngas with a Co/Mn catalyst; and d) converting at least some process hydrogen and at least some process and/or external carbon dioxide to syngas by a reverse water gas shift reaction, and recycling such reverse water gas shift reaction produced syngas to before step c) .
• apparatuses comprising:
• Figure 1 shows a flow diagram of one example of a process and apparatus of the present invention.
• Ranges can be expressed herein as from “about” one particular value, and/or to "about” another particular value. When such a range is expressed, a further aspect includes from the one particular value and/or to the other particular value. Similarly, when values are expressed as approximations, by use of the antecedent "about,” it will be understood that the particular value forms a further aspect. It will be further understood that the endpoints of each of the ranges are significant both in relation to the other endpoint, and independently of the other endpoint. It is also understood that there are a number of values disclosed herein, and that each value is also herein disclosed as "about” that particular value in addition to the value itself. For example, if the value "10” is disclosed, then “about 10" is also disclosed. It is also understood that each unit between two particular units are also disclosed. For example, if 10 and 15 are disclosed, then 11, 12, 13, and 14 are also disclosed.
• references in the specification and concluding claims to parts by weight of a particular element or component in a composition denotes the weight relationship between the element or component and any other elements or components in the composition or article for which a part by weight is expressed.
• X and Y are present at a weight ratio of 2:5, and are present in such ratio regardless of whether additional components are contained in the compound.
• a weight percent (wt. %) of a component is based on the total weight of the formulation or composition in which the component is included.
• the term "substituted" is contemplated to include all permissible substituents of organic compounds.
• the permissible substituents include acyclic and cyclic, branched and unbranched, carbocyclic and heterocyclic, and aromatic and nonaromatic substituents of organic compounds.
• Illustrative substituents include, for example, those described below.
• the permissible substituents can be one or more and the same or different for appropriate organic compounds.
• the heteroatoms, such as nitrogen can have hydrogen substituents and/or any permissible substituents of organic compounds described herein which satisfy the valences of the heteroatoms.
• substitution or “substituted with” include the implicit proviso that such substitution is in accordance with permitted valence of the substituted atom and the substituent, and that the substitution results in a stable compound, e.g., a compound that does not spontaneously undergo transformation such as by rearrangement, cyclization, elimination, etc. it is also contemplated that, in certain aspects, unless expressly indicated to the contrary, individual substituents can be further optionally substituted (i.e., further substituted or unsubstituted).
• Certain materials, compounds, compositions, and components disclosed herein can be obtained commercially or readily synthesized using techniques generally known to those of skill in the art.
• the starting materials and reagents used in preparing the disclosed compounds and compositions are either available from commercial suppliers such as Aldrieh Chemical Co., (Milwaukee, Wis.), Acros Organics (Morris Plains, N.J.), Fisher Scientific (Pittsburgh, Pa.), or Sigma (St.
• compositions of the invention Disclosed are the components to be used to prepare the compositions of the invention as well as the compositions themselves to be used within the methods disclosed herein. These and other materials are disclosed herein, and it is understood that when combinations, subsets, interactions, groups, etc. of these materials are disc losed that while specific reference of each various individual and collective combinations and permutation of these compounds can not be explicitly disclosed, each is specifically contemplated and described herein. For example, if a particular compound is disclosed and discussed and a number of modifications that can be made to a number of molecules including the compounds are discussed, specifically contemplated is each and every combination and permutation of the compound and the modifications that are possible unless specifically indicated to the contrary.
• compositions disclosed herein have certain functions. Disclosed herein are certain structural requirements for performing the disclosed functions, and it is understood that there are a variety of structures that can perform the same function that are related to the disclosed structures, and that these structures will typically achieve the same result,
• the method comprising:
• the method further comprises a step wherein waste water is produced prior to step d).
• the method further comprises a step comprising recovering the waste water; wherein some or all of the recovered waste water is added to the natural gas prior to being introduced.
• the natural gas can comprise methane, various alkanes, carbon dioxide, nitrogen, or hydrogen sulfide or a combination thereof.
• the stream reforming in step b) can be based on any known reforming process, such as Steam Methane Reforming (SMR), Auto Thermal Reforming (ATR). or Partial Oxidation, Adiabatic Pre Reforming (APR), or Gas Heated Reforming (GHR), or any appropriate combination.
• SMR Steam Methane Reforming
• ATR Auto Thermal Reforming
• APR Adiabatic Pre Reforming
• GHR Gas Heated Reforming
• hydrogen and C02 can be converted to syngas using the reverse water gas shift reaction in the reverse water gas shift unit operation (RSR). This can reduce the load on the reforming unit.
• the reactor effluent from the RSR can be combined with the syngas downstream of the steam reforming (SR).
• the hydrogen can be surplus hydrogen from the process, called the process hydrogen
• the C02 can be surplus from the process, called process carbon dioxide, or can be from an outside source, called external carbon dioxide.
• the method further comprises recovering carbon dioxide using an acid gas removal process.
• the method comprises recovering carbon dioxide formed during reforming the natural gas to syngas and/or after converting the syngas to a product mixture.
• the carbon dioxide can be compressed and recycled back to the reforming the natural gas to syngas.
• the reforming step b) comprises contacting the natural gas with steam and recycled carbon dioxide. Carbon dioxide can be recycled back to the steam methane reformer in step b) as feed along with the natural gas feed. Carbon dioxide helps to increase the syngas (carbon monoxide) through a reverse water gas shift reaction in the steam methane reformer. This also helps utilize carbon dioxide and increase carbon efficiency.
• step c the syngas is converted to the product mixture by contacting the syn gas with a Co/Mn catalyst.
• Syngas may be converted into hydrocarbons by a catalytic process which is usually referred to as the Fischer-Tropsch (FT) process. This is for example described by Van der Laan et al. in Catal. Rev.-Sci. Eng., 41, 1999, p. 255.
• the product mixture can comprise at least one olefin, carbon dioxide, and hydrogen.
• the product mixture in addition to the at least one olefin, also typically comprises water, one or more alcohols, and one or more hydrocarbons.
• water and one or more hydrocarbons can be condensed in the aqueous phase.
• the aqueous phase can comprise one or more hydrocarbons or one or more alcohols or a combination thereof. This aqueous phase can be called the waste water.
• the olefin comprises C2-C10 hydrocarbons.
• the olefin comprises carbons ranging from two carbons to ten carbons, including 3, 4. 5, 6, 7, 8, or 9 carbons.
• the range of carbon atoms can be derived from any two preceding values.
• the olefin can comprise carbons ranging from three carbons to nine carbons.
• the olefin comprises at least one double bond. In another aspect, the olefin comprises two double bonds. In a further aspect, the olefin comprises three double bonds.
• the olefin comprises ethylene, propene, 1-butene, l-pentene, 1-heptene, 1-hexene, 2-ethyl-hexylene, 2-ethyl-heptene, 1-octene, 1-nonene, or 1-decene, or a combination thereof.
• the olefin comprises multiple double bonds.
• the olefin can be a diolefin.
• the olefin can be 1,3-butadiene, 1,4-pentadiene, heptadiene, or a combination thereof.
• the olefin can be a cyclic olefin and diolefin.
• the olefin can be cyclopentene, cyciopentadiene, cyciohexene, cyclohexadiene, or methyl cyciopentadiene and the like; or a cyclic diolefindiene, e.g., dicyciopentadiene, methyleyclopentadiene dimer and the like.
• the recovered waste water is used in the natural gas saturator, where natural gas is added to the water at a higher temperature.
• the natural gas is saturated with water.
• one or more hydrocarbons present in the recovered waste water can be stripped out of the natural gas stream. This process thereby can recover the waste water and eliminate, minimize, and/or reduce waste water treatment problems.
• some or all of the recovered waste water is recycled as steam in step b). In another aspect, some or all of the recovered waste water is recovered after step c). In one aspect, some or all of the recovered waste water is recycled after step c). In a further aspect, the waste water is produced from converting the syngas to the product mixture.
• some of the recovered waste water comprises an alcohol or a hydrocarbon, or a combination thereof.
• the alcohol or hydrocarbon or a combination thereof is produced from converting the syngas to the product mixture.
• the alcohol or the hydrocarbon, or the combination thereof is recycled to the reforming of the natural gas to syngas.
• the alcohol can comprise a carbon chain with carbons ranging from two carbons to six carbons.
• the alcohol can comprise a straight or branched carbon chain.
• the alcohol can be a primary, secondary, or tertiary alcohol.
• the alcohol can comprise ethanol, propanol, butanol, pentanol, hexanol, isopropanol, isobutanol, sec-butanol, or tert-butanol, or a combination thereof.
• the hydrocarbon can comprise a carbon chain with carbons ranging from two carbons to six carbons.
• the hydrocarbon can comprise a straight or branched carbon chain.
• the hydrocarbon can comprise ethane, propane, butane, pentane, hexane, or isobutane, or a combination thereof.
• the hydrocarbon can also called be a paraffin.
• the product mixture further comprises a hydrocarbon comprising carbons in an amount ranging from two carbons to five carbons.
• the hydrocarbon can be water soluble.
• the alcohol or the hydrocarbon, or a combination thereof is reformed in step b) with the natural gas to the syngas.
• the alcohol or the hydrocarbon, or a combination thereof can be economically recovered in this method.
• the method further comprises purifying the product mixture by a cryogenic separation process.
• the purifying the product mixture comprises separating methane, nitrogen, hydrogen, or carbon monoxide, or a combination thereof.
• the method comprises recycling the methane or nitrogen, or a combination thereof back to step b).
• the methane and nitrogen recycle stream can be used as fuel in step b).
• the method comprises recycling the hydrogen, or carbon monoxide, or a combination thereof back to step c). This recycling back to step c) can help maintain the required hydrogen to carbon monoxide ratio.
• cryogenic separation process can comprise separating the methane and/or nitrogen.
• the separated methane and/or nitrogen can be recycled to be used as fuel when the natural gas is reformed to syngas.
• hydrogen and/or carbon monoxide can be recycled to be combined with fresh syngas.
• the excess hydrogen can be separated and used in an appropriate reforming process,
• the method comprises recovering heat and/or power from step b).
• the heat can be recovered as high pressure steam.
• the method comprises generating power as electricity.
• the electricity is generated by expanding the hot syngas.
• the syngas comprises carbon monoxide, carbon dioxide, or hydrogen, or a combination thereof. In another aspect, the syngas comprises carbon monoxide and hydrogen.
• the product mixture comprises one or more paraffins, one or more alcohols, water, or carbon dioxide, or a mixture thereof.
• the paraffin can comprise a light paraffin or a heavy paraffin, or a combination thereof.
• the heavy paraffin can comprise an alkane with more than five carbons.
• the light paraffin can comprise an alkane with one carbon to five carbons.
• the conversion of syngas to a product mixture is in the range of from 40 % to 90 %, including exemplary values of 45 %, 50 %, 55 %, 60 %, 65 %, 70 %, 75 %, 80 %, and 85 %.
• the range can be derived from any two exemplary values.
• the conversion of syngas to a product mixture can be in a range of from 45 % to 90 %.
• the product mixture has a hydrocarbon selectivity in the range of from 50 % to 90 % including exemplary values of 55 %, 60 %, 65 %, 70 %, 75 %, 80 %, and 85 %.
• the range can be derived from any two exemplary values.
• the product mixture has a hydrocarbon selectivity in the range of 55 % to 90 %,
• an apparatus comprising:
• a steam reformer which is in fluid communication with a reactor; wherein the steam reformer reforms natural gas to syngas;
• the reactor which is in fluid communication with the saturator; wherein the reactor converts the syngas to a product mixture comprising at least one olefin by contacting the syngas with a Co/Mn catalyst; andreverse water gas shifter, which is in fluid communication with the reactor; wherein at least some hydrogen and at least some carbon dioxide is converted to syngas.
• the apparatus comprises a saturator, which is in fluid
• these apparatus units are not limited to a specific order. In another aspect, these apparatus units are limited to this order.
• the apparatus further comprises an acid gas removal apparatus, which is in fluid communication with the reactor, wherein the acid gas removal apparatus recovers carbon dioxide.
• the apparatus further comprises a cryogenic separation apparatus, which is in fluid communication with the reactor, wherein the cryogenic separation apparatus purifies the olefin.
• the apparatus further comprises a heat and power recovery apparatus after the steam reformer,
• the apparatus further comprises a hydrodesulfurization apparatus before the steam reformer.
• Figure 1 shows a flow diagram of one aspect of the method and the apparatus from Sections B and C above. In another aspect, not all the steps in the flow diagram are required for the inventive apparatus.
• the method starts with introducing the natural gas.
• the natural gas can flow to the hydrodesulftirization (HDS) to purify the natural gas.
• Carbon dioxide can be added between the hydrodesuifurization and the steam reforming.
• the purified natural gas can flow to the steam reforming (SR). Fuel in the form of recycled natural gas, and oxygen can also be added.
• the steam reforming can also use waste water from the heat recovery and cooling to produce steam.
• the steam reforming can reform the natural gas by contacting the natural gas with steam to produce a syngas.
• the syngas can flow to the heat and power recovery (HPR) where the heat and power can be recovered.
• the syngas can then flow to the syngas purification (SGP) where the syngas is purified.
• the purified syngas can then flow to the syngas to olefin (STO) where the olefin, and more typically, olefinic, paraffinic, and oxygenated hydrocarbons are formed.
• STO olefin
• the olefin stream can then flow to the heat recovery and cooling (HRC) where the waste water is removed to be recycled back to the steam reforming.
• the olefin stream can also be purified by removing any wax or hydrocarbons.
• the purified olefin stream can flow to the acid gas removal (AGR) where the carbon dioxide can be removed and recycled to before the steam reforming.
• the purified olefin can flow to the olefin separation (OS) where the olefins are separated into various streams, including the gas stream.
• the gas stream can flow to the recycle gas separation (RGS) where the methane and nitrogen are removed to be recycled back to the SR as fuel. Unreacted hydrogen and carbon monoxide can be separated at the RGS and recycled back to the hydrodesuifurization to be combined with the syngas.
• the hydrodesuifurization can comprise desulfurization in a conventional hydrodesuifurization apparatus.
• the process can be carried out in two catalytic steps.
• an organic sulfur for example mercaptans
• the hydrodesuifurization can require a small amount of hydrogen in the natural gas.
• the 3 ⁇ 4S can be adsorbed onto a ZnO adsorbent.
• the natural gas can comprise other impurities, such as chloride or mercury and can be removed by one or more additional steps.
• the hydrodesuifiirization can be integrated with the steam reformer for any heat requirements,
• the hydrodesuifiirization can be carried out at a temperature ranging from 350 °C to 400 °C temperature, including exemplary values of 360 °C, 370 °C, 380 °C, and 390 °C.
• the range can be derived from any two exemplary values.
• the temperature can range from 360 °C to 400 °C,
• the hydrodesuifiirization can be carried out at a pressure ranging from 30 to 50 bar, including exemplary values of 31 bar, 32 bar, 33 bar, 34 bar, 35 bar, 36 bar, 37 bar, 38 bar, 39 bar, 40 bar, 41 bar, 42 bar, 43 bar, 44 bar, 45 bar, 46 bar, 47 bar, 48 bar, and 49 bar.
• the range can be derived from any two exemplary values.
• the pressure can range from 31 bar to 50 bar.
• the natural gas is reformed into syngas in the steam reforming.
• the natural gas can be reformed either catalytically and/or non- catalytically.
• the natural gas can be reformed to syngas comprising carbon monoxide, carbon dioxide, and/or hydrogen.
• the reforming uses steam, optionally in combination with oxygen, as an oxidant.
• the steam reforming can be in a single step or by combination of many reforming techniques.
• the reforming can use Steam Methane Reforming, Auto Thermal Reforming, Partial Oxidation, Adiabatic Pre Reforming, or Gas Heated Reforming.
• the syngas can be available at a pressure ranging from 30-50 bar and at a temperature ranging from 850 °C to 1300 °C.
• the hot syngas flows to heat and power recovery.
• the heat and power recovery in the heat and power recovery, a significant amount of heat can be recovered from high pressure steam generation.
• the heat and power recovery can generate a considerable amount of electricity by expanding the hot syngas through a hot gas expander coupled with an electricity generator.
• the syngas flows from the heat and power recovery to the syngas purifier.
• the syngas is purified at the syngas purifier.
• the syngas can be at a relatively low temperature and pressure.
• the syngas purifier can remove at least one nitrogenous impurity and/or at least one metal impurity.
• the nitrogenous impurity can comprise N ⁇ , HCN, or ⁇ , or a combination thereof.
• the metal impurity can comprise iron carbonyl, or nickel carbonyl, or a combination thereof. These impurities can act as a poison for the CoMn catalyst used to convert syngas to the product mixture.
• the purified syngas can flow to where the syngas is converted to the product mixture.
• the syngas is converted to the product mixture.
• the purified syngas and the recycled gas is converted to the product mixture.
• the H 2 /CO ratio can be adjusted by the combination of the fresh and recycle syngas streams.
• other parameters also control the hydrogen/carbon monoxide ratio, for example the carbon dioxide recycle to the steam reformer.
• the combined syngas stream with required H 2 /CO ratio and purity can be converted to the product mixture using a CoMn catalyst.
• the conversion is carried out at a temperature ranging from 200 °C to 300 °C, including exemplary values of 210 °C, 220 °C, 230 °C, 240 °C 5 250 °C, 260 °C, 270 °C, 280 °C, and 290 °C.
• the range can be derived from any two exemplary values.
• the temperature can range from 210 °C to 300 °C.
• the conversion is carried out at a pressure ranging from 5 bar to 15 bar, including exemplary values of 6 bar, 7 bar, 8 bar, 9 bar, 10 bar, 1 1 bar, 12 bar, 13 bar, and 14 bar.
• the range can be derived from any two exemplary values.
• the pressure can range from 6 bar to 15 bar.
• the reactor effluent from the conversion of the syngas to the product mixture can be at moderately high temperature and can be subjected to heat recovery by heating the reactor feed stream in a feed-effluent heat exchanger.
• This stream can be further cooled to room temperature in series of gradual cooling steps to facilitate separation of a small amount of one or more paraffins and one or more alcohols along with water, which were produced during the conversion to the product mixture.
• the product mixture can then flow to the heat recovery and cooling where the waste water can be removed and recycled to the steam reformer.
• the product mixture can be purified by removing any wax or hydrocarbons.
• the gas stream is sent to the acid gas removal to remove the carbon dioxide.
• the carbon dioxide can be formed in the steam reformer and/or during the conversion to the product mixture.
• the acid gas removal can use a conventional unit.
• the acid gas removal can use a Benfield unit. After the carbon dioxide has been removed, it can be compressed and recycled back to the steam reformer.
• the product mixture flows to the olefin separation unit.
• the olefin separation unit separates an olefin, a light paraffin hydrocarbon, or a heaw paraffin hydrocarbon, or a combination thereof,
• the product mixture flows to the recycle gas separation.
• the product mixture includes gases from the OS, such as CH4, N2, H2, and/or CO.
• the gas stream can be separated using a cryogenic separation unit.
• the cryogenic separation unit can be any suitable cryogenic separation unit.
• the gas stream can comprise methane, nitrogen, hydrogen, or carbon monoxide, or a combination thereof.
• the methane and nitrogen stream can be separated in the recycle gas separation to be used as a purge gas fuel in the steam reformer.
• the unreacted hydrogen and carbon monoxide can be recycled back and combined with fresh syngas before sending the syngas to be converted to the product mixture.
• the excess hydrogen is also separated in the recycle gas separation. The excess hydrogen can be eliminated by adopting appropriate reforming technology,
• the disclosed methods and apparatuses include at least the following aspects.
• a method comprising:
• Aspect 2 The method according to aspect 1, wherein the method produces waste water prior to step d).
• Aspect 3 The method according to aspect 2, wherein the method recovers the waste water; wherein some or all of the recovered waste water is used to saturate the natural gas prior to being introduced,
• Aspect 4 The method according to any one of aspects 1-3, wherein the method further comprises recovering carbon dioxide using an acid gas removal process.
• Aspect 5 The method according to any of aspects 2-4, wherein some of the recovered waste water is recycled as steam in step b).
• Aspect 6 The method according to any of aspects 2-5, wherein some of the recovered waste water comprises one or more alcohols or one or more hydrocarbons, or a combination thereof.
• Aspect 7 The method according to aspect 6, wherein the one or more alcohols or the one or more hydrocarbons, or a combination thereof is reformed in step b) with the natural gas.
• Aspect 8 The method according to any of aspects 1-7, wherein the method further comprises purifying one or more olefins by a cryogenic separation process.
• Aspect 9 The method according to aspect 8, wherein the purifying the olefin comprises removing methane, nitrogen, hydrogen, or carbon monoxide, or a combination thereof.
• Aspect 10 The method according to aspect 9, wherein the method comprises recycling the methane or nitrogen, or a combination thereof back to step b).
• Aspect 11 The method according to any of aspects 9-10, wherein the method comprises recycling the hydrogen, or carbon monoxide, or a combination thereof back to step c).
• Aspect 12 The method according to any of aspects 1-11, wherein the method comprises recovering heat and/or power from step b).
• Aspect 13 The method according to any of aspects 1-12, wherein the syngas comprises carbon monoxide, carbon dioxide, or hydrogen, or a combination thereof.
• Aspect 14 The method according to any of aspects 1-13, wherein the product mixture further comprises a paraffin, an alcohol, water, or carbon dioxide, or a mixture
• Aspect 15 The method according to any of aspects 1-14, wherein the product mixture further comprises one or more hydrocarbons comprising carbons in an amount ranging from two carbons to five carbons.
• Aspect 16 The method according to any of aspects 1-15, wherein the conversion of the syngas to a product mixture is in the range of from 40 % to 90 %.
• Aspect 17 The method according to any of aspects 1-16, wherein the product mixture has a hydrocarbon selectivity in the range of from 50 % to 90 %.
• Aspect 18 An apparatus comprising:
• a steam reformer which is in fluid communication with a reactor; wherein the steam reformer reforms the natural gas to syngas;
• the reactor which is in fluid communication with the saturator; wherein the reactor converts the syngas to a product mixture comprising at least one olefin by contacting the syngas with a Co/Mn catalyst;
• reverse water gas shifter which is in fluid communication with the reactor; wherein at least some hydrogen and at least some carbon dioxide is converted to syngas.
• Aspect 19 The apparatus according to aspect 18, wherein the apparatus further comprises a saturator, which is in fluid communication with the steam reformer; wherein the saturator recovers waste water.
• Aspect 20 The apparatus according to any one of aspects 18-19, wherein the apparatus further comprises an acid gas removal apparatus, which is in fluid communication with the reactor, wherein the acid gas removal apparatus recovers carbon dioxide.
• Aspect 21 The apparatus according to any of aspects 18-20, wherein the apparatus further comprises a cryogenic separation apparatus, which is in fluid
• cryogenic separation apparatus purifies the at least one olefin.
• Aspect 22 The apparatus according to any of aspects 18-21, wherein the apparatus further comprises a heat and power recovery apparatus after the steam reformer.
• Aspect 23 The apparatus according to any of aspects 18-22, wherein the apparatus further comprises a hydrodesuifurization apparatus before the steam reformer.

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• 2014
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